North American LNG Import Terminals

As of December 2004, there were four operating liquefied natural gas (LNG) import terminals in North America with a combined peak sendout capacity of 3.715 Bcf/d and expansion plans for another 2.44 Bcf/d of sendout capacity. In addition, there were plans for another 49 LNG import terminals with an expected total combined peak sendout capacity of more than 49 Bcf/d. Of those 49 terminals, nine, with a total peak sendout of 10.9 Bcf/d, had received final regulatory approvals. Another 22 projects are already in various stages of the regulatory approval process, and 18 additional LNG projects remain in the planning stages.

Operating Terminals:

1. Cove Point LNG (Planned Expansion) -- Lusby, Maryland; Dominion; Sendout 1 Bcf/d; Planned expansion would add 0.8 Bcf/d of sendout capacity in 2008; Storage capacity rose from 5 Bcf to 7.8 Bcf in December 2004 through the addition of a new 2.8 Bcf LNG storage tank. Storage is expected to increase to 14.6 Bcf in 2008. The 2008 expansion project also would include 47 miles of looping along the Cove Point Pipeline in Maryland, a new 81-mile pipeline in Pennsylvania between Perulack, PA, and Leidy, PA, and various smaller new pipelines and looping projects in Pennsylvania designed to increase transportation of gas between the import terminal and Dominion's many gas storage fields that serve the Northeast and Mid Atlantic regions. Dominion received FERC authorization Aug. 17, 2004 to begin the NEPA prefiling process on the 2008 project. The company held an open season in fall 2004 and said the project was fully subscribed. Statoil has signed a contract for 1.05 Bcf/d of the total 1.8 Bcf/d of planned send-out capacity in the 2008 expansion project. The remaining 750 MMcf/d of capacity will be owned by Shell, BP and peaking customers. In 2003, the company completed its Cove Point East pipeline expansion, which included two new compressor stations with 19,340 of horsepower in Loudoun and Fairfax counties, VA. The $43.5 million project added 445,000 Dth/d in additional firm transportation capacity for Washington Gas Light and Virginia Power Service Energy Corp. FERC approved the resumption of LNG imports at Cove Point in October 2001. The terminal received its first commercial delivery in 23 years in August 2003 from Trinidad and Tobago. Cove Point was originally constructed in the mid 1970s at a cost of $400 million.
2. Elba Island (Expanding) -- Elba Island, Georgia; El Paso; Average sendout 0.44 Bcf/d; Peak sendout 0.68 Bcf/d; Expansion approved by FERC in April 2003 allows the company to add 3.3 Bcf of storage capacity and boost the average sendout rate of the terminal by 0.36 Bcf/d (peak sendout by 0.54 Bcf/d), bringing total storage capacity to 7.3 Bcf and the average sendout rate to about 0.8 Bcf/d. The $148 million project has a targeted completion in the first quarter of 2006. Shell Gas & Power has entered into a binding precedent agreement with Southern LNG to acquire all of the expansion capacity for a 30-year term. Marathon signed contract in 2002 to deliver 58 Bcf/year of LNG to Elba Island for 17 years; BG Group holds rights through December 2023 to market 446 MMcf/d of sendout capacity, including 159 MMcf/d from LNG delivered by Marathon and LNG delivered by BG from Atlantic LNG trains 2 and 3 in Trinidad. Terminal was given authorization by FERC in December 1999 to resume import operations after being idled for 20 years and received its first new shipment on Oct. 2, 2003 from a tanker that was barred from entering the Distrigas terminal in Boston Harbor because of security and safety concerns.
3. Everett LNG -- Everett, Massachusetts; Distrigas of Massachusetts Corp. (Tractebel LNG/Suez); Peak sendout capacity 1.035 Bcf/d; Storage capacity 3.4 Bcf (42 million gallons) in two storage tanks. Distrigas expanded its baseload sendout capacity by 300 MMcf/d to 725 MMcf/d in 2003. Distrigas serves about 20% of New England's annual gas demand. The Distrigas terminal is connected to Algonquin Gas Transmission, Tennessee Gas Pipeline and KeySpan's gas distribution system. Distrigas also provides LNG to customers that have LNG storage tanks through four truck loading bays with a maximum liquid sendout of more than 100 MMcf/d or 1.2 million gallons/day. The terminal received its first shipment of LNG in November 1971.
4. Trunkline LNG (Phase I Expansion Approved; Phase II Pending at FERC) --> Lake Charles, Louisiana; Panhandle Energy (Southern Union); Average sendout capacity 0.63 Bcf/d; Peak sendout capacity 1 Bcf/d; Storage capacity 6.3 Bcf. In December 2002, FERC approved Trunkline LNG's plans to expand the facility to 1.2 Bcf/d of average sendout capacity (1.3 Bcf/d of peak sendout) and 9 Bcf of storage capacity. Plans call for construction of a fourth storage tank and a second unloading dock, giving it the ability to unload two ships simultaneously. The cost of the expansion is $177.2 million, and it has a targeted in-service date of December 2005. A second proposed expansion was filed with FERC in January 2004 and approved in September. It would bring average sendout capacity to 1.8 Bcf/d with peak sendout of 2.1 Bcf/d by mid 2006. The project also calls for the construction of a 23-mile, 36-inch diameter pipeline from the LNG terminal to the mainline of Trunkline Gas, and for construction of additional pumps and vaporizers along with unloading facilities added to a second dock. The new pipeline would parallel an existing pipeline, increasing pipeline capacity from the terminal to 2.1 Bcf/d from 1.3 Bcf/d. BG Group has rights to entire sendout capacity.

Planned and Proposed Terminals

Atlantic Coast

1. Bear Head (Granted Environmental Approval by Canadian and Provincial Governments) -- Point Tupper, Nova Scotia; Access Northeast Energy (purchased by Anadarko); Sendout 1 Bcf/d after Phase I; Service November 2007. The two-phase project involves construction and operation of a 7.5 million ton/year capacity marine LNG terminal, land-based storage tanks and a land-based regasification area with a gas sendout capacity of 1 Bcf/d in Phase I and future expansion of sendout capacity to 1.5 Bcf/d in Phase II. The facilities would deliver gas into the Maritimes and Northeast Pipeline, which serves eastern Canada and Northeast U.S. markets. Nova Scotia Department of Environment and Labour and Canadian Environmental Assessment Agency concluded in August 2004 that the terminal, proposed for construction at the Point Tupper/Bear Head Industrial Park on the Strait of Canso, is not likely to cause significant adverse effects on the environment. It is the first of several approvals required before the company can begin construction.
2. Brayton Point LNG (Planned) -- Somerset, Massachusetts, near Brayton Point Station; Somerset LNG; Peak sendout 0.65 Bcf/d.
3. Broadwater Energy (Planned) -- 11 miles offshore Connecticut in Long Island Sound; TransCanada Corp. and Shell US Gas & Power LLC; Average sendout 1 Bcf/d; Cost $700 million; Service in late 2010. The floating port facility will use a closed system for vaporizers that will not include the use of seawater from the Sound. It will include a 25-mile subsea pipeline to the Iroquois Gas Transmission system. Website: http://www.broadwaterenergy.com/.
4. Cacouna Energy (Planned) -- Gros Cacouna, Quebec, about nine miles northeast of Riviere-du-Loup; TransCanada/Petro-Canada; Cost C$660 million; Sendout 0.5 Bcf/d. Project was announced in late August 2004. Petro-Canada has signed a memorandum of understanding with Russia's Gazprom that could involve operations in all areas of the LNG value chain, from exploration, production and liquefaction, to shipping, regasification and marketing in North America. The agreement covers options for joint development of a US$1.2-1.5 billion liquefaction plant near St. Petersburg, Russia in the Baltic port of Ust Luga, and to investigate options for gas supplies to that LNG plant and then to regasification terminals in North America by 2009.
5. Calypso (FERC Approved Pipeline; Bahamas Granted Preliminary Approval) -- Freeport Grand Bahama Island, Bahamas; Tractebel LNG; Sendout 0.83 Bcf/d; Service expected in 2007. The $132 million 54-mile U.S. portion of the pipeline system between the offshore international boundary and Port Everglades, FL, in Broward County was approved by FERC in March 2004. The U.S. segment of the pipeline, which will have a capacity to deliver 832,000 Dth/d of gas, would travel onshore to a proposed interconnection with Florida Gas Transmission adjacent to Florida Power & Light's (FPL) Ft. Lauderdale power plant. The terminal application is pending in Bahamas. The Bahamian environmental commission is expected to rule soon on the project, which already has preliminary commercial approval from the Ministry of Trade and Industry. Tractebel announced an agreement in December 2004 to combine its Calypso project with El Paso's Seafarer/High Rock LNG project. The companies plan to pursue full regulatory approval of both projects but will move forward with only one, or a combination, of them. FPL Group Resources has an option to buy the Seafarer/High Rock LNG project from El Paso.
6. Canaport (Approved by Canadian and Provincial Governments) -- St John, New Brunswick; Irving Oil; C$500 million; Sendout 1 Bcf/d; Storage capacity 480,000 cubic meters in three 160,000 cubic meter tanks. Canaport received final approval from Canadian agencies in August 2004. Approvals were issued by the New Brunswick Department of Environment and Local Government, Environment Canada, and Fisheries and Oceans Canada, in accordance with the provincial Environmental Assessment Regulations and the federal Canadian Environmental Assessment Act. The facility will be located 65 miles from the U.S. border and will be connected via pipeline to the 250,000 bbl/d Irving Oil refinery, which is five miles away.
7. Crown Landing (Pending at FERC) -- Logan Township, New Jersey, adjacent to Delaware River; BP; Sendout 1.2 Bcf/d; Service 2009; Connections planned to three major Northeast interstate pipelines.
8. Freedom Energy Center  (Planned) -- Philadelphia, PA, along the Delaware River; Philadelphia Gas Works; Sendout 0.6 Bcf/d; Project would involve conversion of PGW's existing Port Richmond LNG plant into an import terminal near the Tioga Marine Terminal on the North Delaware Riverfront. The existing plant, which was built in the early 1970s as a means of ensuring a reliable supply of natural gas for Philadelphia, currently has about 23.5 MMcf/d of natural gas liquefaction capacity, two storage tanks capable of holding a total of about 4.1 Bcf of gas and vaporization capacity totaling about 450 MMcf/d. It is the largest peak shaving LNG plant in North America.
9. High Rock LNG (Pipeline Pending at FERC; Terminal Pending in Bahamas) -- Grand Bahama Island, Bahamas; El Paso (FPL Group has option to buy 100% of the project); Sendout 1 Bcf/d. The U.S. portion of the $226 million, 163-mile Seafarer Pipeline is pending at FERC. The High Rock LNG terminal on Grand Bahama Island is pending in Bahamas. Tractebel announced an agreement in December 2004 to combine its Calypso project with El Paso's Seafarer/High Rock LNG project. The companies plan to pursue full regulatory approval of both projects but will move forward with only one, or a combination, of them.
10. Keltic LNG (Planned) -- Goldboro, Nova Scotia; Keltic Petrochemicals; Sendout 0.5 Bcf/d in 2007, 1.9 Bcf/d in 2009; Terminal to be located at the beginning of the Maritimes and Northeast Pipeline system.
11. Northeast Gateway (Planned) -- offshore Gloucester, Massachusetts; Excelerate Energy LLC; Sendout 0.8 Bcf/d; Cost $200 million; Service 2007; Expected to be connected to Duke Energy's HubLine pipeline system in Massachusetts Bay through 12 miles of 24-inch diameter pipeline.
12. Ocean Express (FERC Approved Pipeline; Terminal Pending in Bahamas) -- Ocean Cay, Bahamas; AES Corp.; Sendout 0.84 Bcf/d; Service in mid 2006. The 54-mile U.S. pipeline portion of the $440 million project has been approved by FERC. The LNG terminal is pending in Bahamas. AES is dredging sand and soil to create its own 90-acre industrial island, called Ocean Cay, for its LNG terminal.
13. Point Tupper (Planned) -- Statia Terminals Canada; Sendout 0.5 Bcf/d. Statia Terminals operates the Point Tupper terminal in the Strait of Canso in Nova Scotia. Its primary function is transshipment of crude oil and refined petroleum products. It has 1.2 million cubic meters of capacity.
14. Providence LNG (Pending at FERC; Received DEIS) -- Fields Point, Rhode Island; KeySpan/BG Group; Sendout 0.525 Bcf/d; Cost $50 million; Service in November 2005. KeySpan filed a plan with FERC in April 2004 to convert the existing 600,000 bbl LNG storage terminal in Providence, RI, to an import terminal. KeySpan signed an agreement in October 2003 with BG Group to undertake the conversion project. Algonquin Gas Transmission plans to build 1.44 miles of 24-inch pipe with 500 MMcf/d of transportation capacity to connect to the KeySpan facility with service in November 2005; LNG terminal project has encountered opposition from Rhode Island Attorney General Patrick C. Lynch and Rhode Island Gov. Donald L. Carcieri because of safety and security concerns. FERC granted the terminal a favorable draft environmental impact statement in December 2004.
15. Rabaska (Pending at Canadian and Provincial Agencies) -- Ville Guay, Quebec; Gaz Metro, Enbridge, Gaz de France; Cost C$700 million; 0.5 Bcf/d; Storage 320,000 cubic meters in two tanks each with capacity of 160,000 cubic meters; Service in first quarter of 2009.
16. Quoddy Bay (Planned) -- Pleasant Point, ME (near Perry, Maine, in Washington County); Passamaquoddy/Sipayik Reservation; Sendout 0.5 Bcf/d, expandable to 1 Bcf/d; Cost $400 million. The terminal would be located adjacent to the commercial shipping port at Eastport, ME, 40 miles east of the Maritimes and Northeast Pipeline. Members of the Passamaquoddy Native American tribe voted in August 2004 in favor of locating the import terminal on their Sipayik Reservation on Passamaquoddy Bay on the northern Maine coast. Project sponsors Quoddy Bay LLC plan to file FERC application in December 2004.
17. Weaver's Cove (Pending at FERC; Received DEIS) -- Fall River, MA; Poten & Partners/Amerada Hess; Sendout of 0.4 Bcf/d on average and 0.8 Bcf/d at peak; 0.1 Bcf/d deliverable by truck; Storage capacity for 4.4 Bcf; Cost $250 million. The project would take up 68 acres of the 73-acre site on the Taunton River feeding into Mount Hope Bay and Narragansett Bay, about 50 miles south of Boston. FERC issued a favorable draft environmental impact statement on the project in August 2004, but noted there was local opposition and the project would need Coastal Zone Consistency Reviews in Massachusetts and Rhode Island.

Gulf Coast

18. Altamira (Approved by State and Federal Mexican Agencies) -- Altamira, Tamaulipas, Mexico; Shell/Total; Sendout 0.5 Bcf/d, expandable to 1.3 Bcf/d; Two storage tanks, each with a capacity of 150,000 cubic meters; Project cost $370 million; Construction has started.
19. Calhoun LNG (Planned) -- Port Lavaca, TX; Gulf Coast LNG Partners; Peak sendout 1 Bcf/d; Cost $400 million; Two 3.5 Bcf storage tanks.
20. Cameron LNG (Approved by FERC) -- Hackberry, Louisiana, 15 miles south of Lake Charles; Sempra Energy; Peak sendout 1.5 Bcf/d; Service 2007; Cost $700 million. Sempra expects to have supply agreements in place before the end of the year but supply available to North America is expected to be tight until 2008, according to CEO Stephen Baum.
21. Compass Port (Pending at Coast Guard/Maritime Administration) -- Gulf of Mexico offshore Alabama (11 miles south of Dauphin Island); Compass Port LLC (ConocoPhillips); Sendout 1 Bcf/d; Storage capacity 300,000 cubic meters in two storage tanks; Cost $500-800 million; Awaiting Coast Guard approval. The Coast Guard held scoping meetings in April regarding the proposed pipeline system and is expected to release a draft environmental impact statement on the project in the next few months. Compass Port would connect with Gulfstream Natural Gas System, Transcontinental Gas Pipe Line and Gulf South Pipeline Co. LP. The proposed 31 mile takeaway pipeline would have the capacity to transport 1 Bcf/d.
22. Corpus Christi (Pending at FERC, Received DEIS) -- Corpus Christi, Texas; Cheniere LNG; Sendout capacity 2.6 Bcf/d; Three 160,000 cubic meter storage tanks; Service in late 2007. Cheniere received favorable a draft environmental impact statement from FERC in November 2004.
23. Creole Trail (Planned) -- mouth of the Calcasieu Channel in Cameron Parish, LA; Cheniere LNG; Peak sendout 2.6 Bcf/d, two docks, three 160,000-cubic-meter storage tanks (10.1 Bcf of capacity).
24. Freeport LNG (Approved by FERC) -- Freeport, TX, on Quintana Island in Brazoria County; Cheniere/Contango/ConocoPhillips/Dow Chemical; Project cost $500 million; Sendout 1.5 Bcf/d; Storage capacity 7 Bcf; 9.4 mile pipeline to Stratton Ridge. Service in second half of 2007; On June, 18, 2004, FERC awarded Freeport LNG Development LP authorization under Section 3 of the Natural Gas Act to site, construct and operate the import terminal. ConocoPhillips has signed an agreement to fund construction of the terminal in exchange for 1 Bcf/d of the regasification capacity.
25. Golden Pass (Pending at FERC) -- Sabine Pass, Texas, 10 miles south of Port Arthur; ExxonMobil; 1 Bcf/d, expandable to 2 Bcf/d; Project cost $600 million; Service in late 2008; Project could include two 36-inch diameter pipelines, one 43 miles long and the other 77 miles long, to an intrastate pipeline in Orange County, TX, and interstate lines in Calcasieu Parish, LA. In addition, a two-mile 24-inch diameter line would carry gas to ExxonMobil's Beaumont refinery. ExxonMobil and Qatar Petroleum have signed an agreement to supply 15.6 million tons a year of LNG (2 Bcf/d) to the United States from Qatar for 25 years. Filed with FERC in November 2003.
26. Gulf Landing (Pending at Coast Guard/Maritime Administration) -- West Cameron Block 213 about 38 miles offshore, Louisiana; Shell US Gas & Power LLC (Royal Dutch/Shell); Service in 2008 or 2009; Sendout 1 Bcf/d.
27. Gulf LNG Energy (Pending at FERC) -- Pascagoula, MS; Gulf LNG Energy LLC; Average sendout 1 Bcf/d; Cost $450 million; Service expected in 2009; Gulf LNG Energy, which began the National Environmental Policy Act pre-filing process at FERC in December, has executed an agreement with the Port of Pascagoula for the right to build the LNG terminal on lands in Bayou Casotte that are owned or controlled by the Jackson County Port Authority.
28. HiLoad LNG (Planned) -- offshore Tamaulipas, Mexico; Peak sendout 1.4 Bcf/d; San Antonio-based Tidelands Oil & Gas Corp. The project would be capable of delivering 500 MMBtu/d to Mexico; 450 MMBtu/d to proposed storage in Mexico's Burgos Basin and 500 MMBtu/d to U.S. markets. Tidelands has signed an agreement with Remora Technology to use Remora's HiLoad LNG Regasification Terminal design, which has been funded in part by ConocoPhillips. The design is for a floating terminal that attaches to an LNG tanker and directly vaporizes the LNG as it is offloaded, eliminating the need for above ground storage tanks. The terminal will inject gas directly into offshore pipelines at rates between 250 MMcf/d and 1.4 Bcf/d.
29. Ingleside Energy Center (Pending at FERC) -- Ingleside, Texas, near Corpus Christi; Occidental Petroleum; Cost $400 million; Sendout 1 Bcf/d; Service 2007; Started NEPA pre-filing process at FERC in April 2004 and certificate application was filed in November; The terminal will have two LNG storage tanks, each with a capacity of one million barrels. The terminal will be capable of unloading 140 ships per year. Occidental said it plans to use only about 10% of the proposed send-out capacity from the terminal for its own operations, with the remainder of the LNG-sourced gas going directly into intrastate and interstate pipelines serving the southern, midwestern and eastern markets. Occidental affiliate San Patricio Pipeline LLC filed an application to build a 26-mile, 1 Bcf/d pipeline that would extend from the proposed terminal along the Texas coast to interconnections with nine existing intrastate and interstate pipelines.
30. Louisiana Energy Bridge (Approved by Coast Guard/Maritime Administration) -- offshore Louisiana (40 miles offshore); El Paso Corp./Excelerate Energy LLC; Sendout 0.5 Bcf/d; Cost $60 million; Service in early 2005; Approved by the Coast Guard. A Korean company is building three specialized 138,000 cubic meter LNG cargo ships for Excelerate. The ships are being built with unique and untested onboard regasification systems that will allow them to deliver regassified LNG into specialized buoys offshore that will be connected to pipelines that will bring the gas to shore. The terminal is expected to be operational in January 2005, but it probably will not receive first spot cargo deliveries until mid 2005 or later because of constraints on the supply side. Excelerate said there are 10 liquefaction projects under construction, five of which are due online in 2005. Two liquefaction trains are being built in Egypt, two in Nigeria and one in Trinidad. As of June 2004, Excelerate had not lined up long-term supply or market agreements for its Louisiana Energy Bridge. The company also is planning an Energy Bridge offshore Gloucester, MA.
31. Main Pass Energy Hub (Pipeline Pending at FERC; Terminal Pending at Coast Guard/Maritime Administration) -- Main Pass Block 299 offshore, Louisiana, 37 miles east of Venice, LA; Freeport-McMoRan; Service in late 2007; Cost $440 million; Sendout 1 Bcf/d; Storage capacity of 250,000 cubic meters. The project includes a proposed 28 Bcf salt dome natural gas storage facility with peak deliverability (including terminal vaporization) of 2.5 Bcf/d. A terminal application has been filed with the Coast Guard and a pipeline application was filed with FERC in March 2004 (watch McMoRan's Main Pass Energy Hub Video). Website: http://www.mpeh.com/.
32. Pearl Crossing (Pending with Coast Guard/Maritime Administration) -- Gulf of Mexico offshore Louisiana, 40 miles south of Cameron Parish; ExxonMobil; Sendout 1 Bcf/d with expansion capability to 2 Bcf/d; Startup in 2008; Filed in May with Coast Guard. Two storage tanks with 125,000 cubic meters each. Two 42-inch diameter pipeline to Starks, LA.
33. Port Pelican (Approved by Coast Guard/Maritime Administration) -- Vermillion Block 140, 40 miles offshore Louisiana; ChevronTexaco; Cost $800 million; Sendout 1.6 Bcf/d; Service 2009; In November 2003, Port Pelican received Coast Guard approval and approval for a deepwater port license from the Maritime Administration of the Department of Transportation, paving the way for the company to begin construction. However, ChevronTexaco pushed back the timing of service from 2007 to 2009 because of required upstream supply agreements. The terminal potentially could receive LNG from three proposed liquefaction terminals in Angola, Nigeria and Venezuela. The Angola and Nigeria liquefaction projects won't be operational until 2009.
34. Port Arthur (Pending at FERC) -- Port Arthur, Texas; Sempra Energy; Sendout 1.5 Bcf/d, expandable to 3 Bcf/d; Cost $600 million; Storage 480,000 cubic meters in three 160,000 cubic meter storage tanks; Service in 2009. The Port Arthur LNG project would feature two unloading berths, and would be capable of doubling its storage capacity in the future to accommodate three additional storage tanks and additional facilities.
35. Sabine Pass (Approved by FERC) -- Sabine Pass, Louisiana; Cheniere LNG; Peak sendout 2.6 Bcf/d; Cost $750 million; Three 160,000 cubic meter storage tanks (10.1 Bcf of storage space); Service in late 2007. Project, which was approved by FERC in December 2004 would include a 16-mile 42-inch diameter pipeline that would link the terminal to Natural Gas Pipeline Co. of America (NGPL) in Johnson's Bayou, LA. From there, the pipeline will extend to another connection with NGPL and to connections with Transcontinental Gas Pipe Line, Texas Gas Transmission, Louisiana Resources Pipeline Co. and others pipelines in the Gulf Coast region. ChevronTexaco Global Gas signed a 20-year agreement for 700 MMcf/d of reserved regasification capacity. The agreement also includes options to reduce or expand capacity to 500 MMcf/d or 1 Bcf/d, respectively. Sabine's other large capacity holder is Total LNG USA with a reservation for 1 Bcf/d for 20 years starting in April 2009. Cheniere LNG will retain the balance of the capacity.
36. Vista del Sol (Pending at FERC, Received DEIS) -- Quintana Island, San Patricio County, Texas, about two miles west of Ingleside; ExxonMobil; Cost $600 million; Sendout capacity 1 Bcf/d; Project also would include a 25-mile, 36-inch diameter gas pipeline with a capacity to deliver 1.4 Bcf/d of gas. Service expected in 2008. A favorable draft environmental impact statement was released by FERC in December 2004. ExxonMobil's LNG supply is expected to come from Qatar. In October, ExxonMobil and Qatar Petroleum announced an agreement to supply 15.6 million tons a year of LNG, or 2 Bcf/d, to the United States for 25 years.

Pacific Coast

37. Cabrillo Port (Pending at Coast Guard/Maritime Administration and California State Lands Commission) -- 21.5 miles offshore Oxnard, California; BHP Billiton; Sendout 0.8 Bcf/d on average and 1.5 Bcf/d at peak; Storage capacity for 6 Bcf of gas; Cost expected to be $550 million; Service expected in 2008; Filed with California State Lands Commission and the Coast Guard for permits.
38. Clearwater Port (Pending at Coast Guard/Maritime Administration and California State Lands Commission) -- offshore Oxnard, California; Crystal Energy LLC; Sendout 0.8 Bcf/d; Cost $300 million; Service 2007; Filed with California State Lands Commission and the Coast Guard for permits; Crystal plans to convert an idled oil platform, Platform Grace, 13 miles offshore Ventura County, CA, into an import terminal and build a 12.6 mile pipeline to a connection with Southern California Gas Co.'s backbone pipeline onshore. Crystal also is working on an LNG supply agreement with the Alaska Gasline Port Authority. Australia's Woodside Energy Inc. will provide funding to Crystal to obtain required project approvals through federal, state and local agencies in exchange for giving Woodside, a major producer on Australia's Northwest Shelf, preferential access rights to Clearwater's terminal capacity. Woodside also will help build and will operate the terminal.
39. Energy Costa Azul LNG (Approved by State and Federal Mexican Agencies, including the Comision Reguladora de Energia) -- a few miles north of Ensenada, onshore Baja California Norte, Mexico; Sempra/Shell; Sendout 1 Bcf/d; Service in 2008; Cost $600 million; Permits have been issued; Road construction underway; Terminal construction expected to begin before the end of 2004; Supply agreements being negotiated with the Indonesian government and BP Indonesia. Shell also will bring LNG supply from the Sakhalin II project in eastern Russia, where Shell is the largest shareholder. Sempra and Shell said 500 MMcf/d will be used to serve the Mexican gas market and the remaining 500 MMcf/d will serve Southern California and the southwestern United States through the North Baja pipeline system.
40. Jordan Cove (Planned) -- Coos Bay, OR; Energy Projects Development LLC (EPD) of Evergreen, CO; Average sendout 150 MMcf/d; Cost $150 million; Storage capacity 95,000 cubic meters in one storage tank; Service in early 2009.
41. Kitimat LNG (Planned) -- Kitimat, British Columbia; Galveston LNG; Sendout 0.34 Bcf/d.
42. Lazaro Cardenas (Pending at Mexican Regulatory Agencies) -- Lazaro Cardenas, Mexico on Central Mexico's Pacific Coast; Tractebel/Repsol; Sendout 0.5 Bcf/d; Tractebel LNG plans to purchase 2.7 million metric tons of LNG each year for 18 years from Hunt Oil's PERU LNG Co., which is expected to begin service in Pampa Melchorita, Peru in early 2008.
43. Long Beach LNG (Pending at FERC) -- Long Beach, California; Sound Energy Solutions (Mitsubishi)/ConocoPhillips; Sendout 0.7 Bcf/d; In a declaratory order issued in March 2004, the Federal Energy Regulatory Commission said it had exclusive jurisdiction over the terminal under Section 3 of the Natural Gas Act (NGA). The California Public Utility Commission is challenging that authority at the U.S. Court of Appeals for the DC Circuit. The CPUC has ruled that the terminal is a utility and falls under state regulatory authority. FERC also has ruled that the California Coastal Commission has federally delegated authority over the project under the Coastal Zone Management Act.
44. Offshore California (Planned) -- Offshore California; ChevronTexaco; Sendout 0.75 Bcf/d.
45. Port Westward (Planned) -- St. Helens, Oregon; Port Westward LNG LLC; 0.7 Bcf/d.
46. Prince Rupert (Planned) -- Prince Rupert, British Columbia; WestPac Terminals; Sendout 0.30 Bcf/d.
47. Puerto Libertad (Pending at Mexican Regulatory Agencies) -- Puerto Libertad, Mexico; Gulf of California, Sonora Pacific LNG (DKRW Energy LLC); Sendout 1.3 Bcf/d; Service in mid-2008; About 500 MMcf/d of regasified LNG deliveries are expected to be directed to the Sonora marketplace with the remaining 800 MMcf/d delivered to markets in the southwestern United States via pipeline connections planned with El Paso Natural Gas, which is building the pipeline infrastructure. DKRW recently purchased 1,500 acres of property from the state of Sonora, Mexico.
48. Skipanon LNG  (Planned) -- Astoria, OR, at mouth of the Columbia River; Calpine Corp.; Sendout 1 Bcf/d; Cost $500 million; Service expected in 2011. Calpine envisions building a 41-mile, 36-inch diameter natural gas pipeline across the Columbia River in an easterly direction to connect with The Williams Co.'s Northwest Pipeline system at Longview, WA.
49. Terminal GNL Mar Adentro (Pending at Mexican Regulatory Agencies) -- 8 miles offshore Tijuana, Baja California Norte, Mexico near the Coronado Islands; ChevronTexaco; Average sendout 0.75 Bcf/d with peak sendout of 1.4 Bcf/d; Cost $650 million; Storage capacity 250,000 cubic meters; Service in 2009 (pushed back from 2007 to coincide with upstream supply projects). ChevronTexaco plans to transport LNG from the Gorgon gas fields off Western Australia to the Baja California terminal using double-hulled LNG carriers, but the Gorgon liquefaction project also will not be operational until 2009 or 2010.

Canceled Terminals

1. Brownsville -- Brownsville, Texas; Cheniere LNG; Sendout 1.5. The project was in the early planning stages. Cheniere had an option on a site for the terminal but never activated it.
2. Fairwinds LNG -- Harpswell, ME; TransCanada/ConocoPhillips; Cost $350 million; Sendout 0.5 Bcf/d; Service 2009; Canceled because of local opposition; Town residents voted not to lease a former U.S. Navy Fuel Depot site to build the LNG terminal and regasification facilities. The town is located 15 miles northwest of Portland, ME.
3. Hope Island LNG -- Hope Island, Maine (near Cumberland); TransCanada/ConocoPhillips; Canceled because of local opposition.
4. Humbolt Bay LNG -- Eureka, CA, Samoa Point; Calpine Corp.; Canceled because of local opposition. Project would have included 155-mile pipeline and 220 MW power plant.
5. Mare Island LNG -- Vallejo, CA; Shell US Gas and Power/Bechtel Enterprises; Cost $1.5 billion; Canceled because of cost, shipping scheduling and local opposition due to safety concerns. Tankers would be escorted by Coast Guard under several major bridges including the Golden Gate Bridge and through San Francisco Bay. Mare Island is a former Navy base located about 25 miles northeast of San Francisco.
6. Navy Homeport LNG -- Mobile, AL, ExxonMobil; Sendout 1 Bcf/d; Project cost $600 million; Service originally expected in 2009. ExxonMobil paid $38 million in 2003 for a three-year option on 200 acres of land along Mobile Bay south of the Mobile city limits. It never filed an application with FERC for the terminal. A series of articles in the local Mobile Register newspaper in fall of 2003 highlighted safety issues regarding LNG terminals. Subsequently, Alabama Gov. Robert Riley warned FERC and the state port authority that he would block the sale of state-owned land outside of Mobile to ExxonMobil to site the import terminal unless the agency first conducted an independent, site-specific study of the potential hazards facing the public. The company released a statement on Oct. 29, 2004 saying that it was "no longer in our business interests" to maintain the Alabama State Docks site, the planned site for the LNG facility, by extending the company's option to purchase it. ExxonMobil, which had already made $1.5 million in option payments on the property, said it did not intend to make another $1.5 million payment that was due Nov. 1.
7. New Jersey Energy Bridge -- Belmar, NJ; El Paso Corp.; Canceled.
8. Pinto Island -- Mobile Bay, Alabama; Cheniere LNG; Sendout 1 Bcf/d; Cheniere had an option on a site but never activated it. There was considerable local opposition to an LNG terminal being located in Mobile (see Navy Homeport LNG above).
9. Tampa LNG -- Tampa, Florida; BP; Canceled.
10. Tijuana Regional Energy Center -- Baja California Norte; Marathon; Sendout 0.75 Bcf/d; Canceled because of local/political opposition. Mexican authorities took back property leases Marathon held for the project. Project also was to include a 1,200 MW power plant, a 20 million gallon seawater desalinization plant and a wastewater treatment facility. Marathon had expected to have the complex in service in 2006.